GB2080368A - Hydraulically set well packer - Google Patents
Hydraulically set well packer Download PDFInfo
- Publication number
- GB2080368A GB2080368A GB8121566A GB8121566A GB2080368A GB 2080368 A GB2080368 A GB 2080368A GB 8121566 A GB8121566 A GB 8121566A GB 8121566 A GB8121566 A GB 8121566A GB 2080368 A GB2080368 A GB 2080368A
- Authority
- GB
- United Kingdom
- Prior art keywords
- mandrel
- packer
- pressure
- inner mandrel
- release
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/129—Packers; Plugs with mechanical slips for hooking into the casing
- E21B33/1295—Packers; Plugs with mechanical slips for hooking into the casing actuated by fluid pressure
Description
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GB 2 080 368 A 1
SPECIFICATION Hydraulically Set Well Packer
The invention relates to packers of the type adapted to be set and anchored in a well bored 5 casing by fluid pressure, to form a seal between a tubing string and the casing without longitudinal or rotational manipulation of the tubing string.
Fluid pressure set well packers are well known including, as examples, those shown and 10 described in U.S. Patent Specifications Nos. 3,112,796, 3,131,769 and British Patent Specification No. 2021178.
Under some circumstances, such packers may not be conveniently set within the well, primarily 15 for the reason that the inner mandrel or body of the packer may extend entirely through the packer from top to bottom. Hence, in order to set such a packer, it may by necessary to blank the tubing below the packer which might result in a 20 hydraulic load being imposed on the packer inner mandrel body which might prevent upward shifting of such body during the setting of the packer. Such action, in turn, may prevent all of the available setting force from being applied to the 25 expandable elements of the packer.
A packer according to the invention that can be fitted within a well conduit includes an elongated tubular body that can be connected to a running tubing string and that comprises co-axially 30 relatively movable inner and outer mandrels,
normally retracted slip means on the tubular body and that may be expanded into engagement with the conduit, resilient packing means on the body and that may be deformed into sealing 35 engagement with the conduit, means responsive to the pressure of fluid in the bore of the body for producing relative axial movement of the mandrels, a member adjacent the lower portions of the outer mandrel and extending axially below 40 the end of the inner mandrel, and means mounted on the member for closing fluid passage through the packer, whereby tubing pressure may then be raised and the inner mandrel may be shifted axially relative to the outer mandrel under the 45 influence of the tubing pressure to facilitate the action of the pressure responsive means.
The packer generally also comprises a slip camming sleeve surrounding the outer mandrel and means for securing the member to the sleeve, , 50 thereby fixing the axial position of the slip camming sleeve.
The means responsive to pressure of fluid in the bore are preferably responsive to increased fluid pressure in the bore for axially shifting the 55 outer mandrel relative to the inner mandrel. The packer may also include setting means mounted on the outer mandrel for expanding the slip means and deforming the packing means, the setting means including the said member and a 60 camming sleeve surrounding said outer mandrel but axially movable relative thereto, sleeve means for connecting said member to said camming sleeve, thereby axially positioning said camming sleeve, locking means for holding the outer and inner mandrels in their pressure shifted position, and means responsive to the relative movement of said outer and inner mandrels with respect to the camming sleeve for operating the setting means. It may also comprise latch means releasably responsive to fluid pressure in the tubing to prevent relative movement of the mandrels until the fluid pressure reaches a predetermined level.
In a preferred fluid pressure operated well conduit packer according to the invention the inner mandrel is an elongated tubular body, the outer mandrel is longitudinally shiftable on the inner mandrel body and the slip means and the packing means are on the outer mandrel, and the packer also includes locking means permitting relative longitudinal shifting of the outer mandrel in one direction with respect to the inner mandrel and preventing relative longitudinal shifting in the other direction, and there is a camming sleeve engageable with the slip means upon the occurrence of the relative longitudinal shifting of the outer mandrel structure with respect to the inner mandrel body in the one direction, an elongated sleeve connected at its top end to the camming sleeve and at its lower end to the said member which extends beyond the lower ends of both the inner mandrel body and the outer mandrel structure, the sleeve being radially spaced from the inner mandrel body and defining an annular pressure chamber that serves as the pressure responsive means, latching means for securing said outer mandrel structure to said inner mandrel body and an unlatching piston disposed in said annular chamber and operable by an increase in tubing pressure to release the latching means, and fluid passage means from the bore to the annular chamber, and in this packer the means for closing the fluid passage through the member permit fluid pressure within the bore of the inner mandrel to be increased to a predetermined level effective to release the latching means.
The annular fluid chamber may also include a packing release piston disposed between two additional axially spaced fluid passage means leading from said bore into said chamber, release means insertable in the inner mandrel body and having a low pressure chamber and a member shiftable from one position at which each passage means is in communication between the bore of the inner mandrel body and the release piston chamber to another position at which only one of the passage means communicates with the low pressure chamber, thereby producing an axial shifting of the release piston, and releasable means on the inner mandrel body engageable by the piston to release the inner mandrel body for upward movement to release the packing means and the slip means. The releasable means may constitute a shearable member engaged by the release piston. The release means may include means for removably supporting them in the inner mandrel body and may include means connectable to a running tool to permit removable
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disposal of the release means in the body.
The packer may include an isolation sleeve secured to the bottom end of the inner mandrel and which slidably engages the interior bore of 5 the said member, and there may be two additional fluid passage means formed in the isolation sleeve.
The said member generally surrounds the lower portions of the outer mandrel. The slip 10 means are generally expanded and the resilient packing means are generally operated by relative axial movement of the mandrels and when the packer is fitted in the conduit it is generally so fitted that the raised tubing pressure shifts the 15 inner mandrel axially upward.
The slip means may be radially shiftable into engagement with the conduit, when the packer is in position, and similarly the packing means may be deformable outwardly into sealing enagement 20 with the conduit. The upper end of the inner mandrel body may be provided with means for connecting wire line and the packer may be constructed so that the application of an upward force by wire line to the inner mandrel body will 25 effect mechanical release of the packer.
As a result of the invention it is now possible to provide an improved fluid pressure actuated packer of the type employing a tubular inner mandrel connectable in a tubing string and having 30 slips and resilient packing means normally retracted to allow running of the packer, on the tubing string. Setting means for expanding the slips and the packing means include an outer mandrel and housing structure on the tubular 35 inner mandrel and defining therebetween an atmospheric chamber and an operating pressure chamber. Releasable means are provided to hold the mandrels and the housing against relative longitudinal movement until the releasable means 40 is pressurised through the tubing to cause release.
The tubing pressure is applied to a blanking valve or plug which is mounted at the lower end of the outer housing, below the inner mandrel, thereby permitting relative upward movement of 45 the inner mandrel with respect to the outer mandrel during the tubing pressurisation. Upon release of the releasable means, hydrostatic pressure acts on the outer mandrel structure to shift it downwardly relative to the housing and the 50 inner mandrel to set the slips and to deform the packing outwardly into sealing engagement with the casing. A ratcheting lock permits relative movement of the mandrels to set the packer and locks the setting force into the resilient packing 55 between the mandrels and the housing. The inner mandrel and the housing also define therebetween a releasing piston chamber, in which a release piston is pressure balanced in a position limiting relative axial displacement of the 60 housing and inner mandrel.
Upon landing a release tool in the inner packer mandrel and operating the release tool to bleed the released piston chamber at one side of the release piston to an atmospheric chamber in the 65 release tool, the applied tubing pressure shifts the release piston to cause release of the inner mandrel and the housing, enabling relaxation of the packing and retraction of the slips.
The invention is now described with reference to the accompanying drawings in which:—
Figure 1 a—1 d together constitute a vertical elevational view, partly in section, of a packer and an on-off sealing connector with the components thereof in the positions occupied during the running in of the packer into the well casing.
Figures 2a—2c together constitute a vertical elevational view, partly in section, corresponding? respectively to Figures 1 b, 1 c and 1 d, but with the components of the packer shown in their set position.
Figures 3a—3b together constitute a side elevational view, partly in section, of a packer embodying this invention having a fluid pressure actuated releasing tool inserted within the bore of the packer in its set condition. Figure 3b being a continuation of Figure 3a.
Figure 4a is a view similar to Figure 3b, illustrating the position of the elements of the assembly after operation of the fluid pressure actuated releasing tool to release the packer from its set condition.
Referring first to Figures 1 a through 1 d, a double grip, pressure set and pressure released packer P is connected by an on-off sealing connector S in a running string of pipe or tubing T, by which the packer P is adapted to be lowered from the top of the well to the selected location in a well casing C. The packer P may be the only packer in the tubing string T or it may be incorporated in a plural packer set-up, that is, the lower packer in a multiple string packer hook-up or in a plural packer single tubing string. The packer P is adaptable to such a variety of installations inasmuch at it is pressure set and normally pressure released without requiring tubing string manipulation.
An elongated inner mandrel body 10 extends through the packer and has an upper threaded end 11 engaged in the lower end 117 of the on-off sealing connector S. At its lower threaded end 13, the mandrel body 10 is threadably connected to an isolation sleeve 14.
Disposed about the inner mandrel body 10 is an outer mandrel structure 15, including a lower, connector mandrel section 1 6 and an upper packing mandrel section 17 joined together at a . threaded joint 18, below which is a downwardly facing internal shoulder 16a. At its upper end, the packing mandrel 17 is threadably engated at 20 _ in a head 21 of hold-down means or "buttons" 22, below which is resiliently deformable packing means 23 adapted to be axially and circumferentially deformed outwardly into sealing engagement in the casing C, between the hold-down head 21 and lower anchor slip means 24, when the packer P is set.
Below the slip means 24, and co-axially disposed about the connector mandrel section 16 and the lower portions of inner mandrel body 10, is a tubular housing 25 which is threadably
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connected at its lower end 26 to a radially enlarged top portion of a bottom sub member 5. The lower portion of the bottom sub 5 is threaded at 5a for connection to an additional length of tubing, or to a bottom anchor or the like. The bottom sub 5 defines an upwardly facing shoulder 5b which is engaged with the bottom of an isolation sleeve 14 in the pre-set or running-in position. The top end of the housing 25 is threadably secured, as at 58, to the lower threaded end of a slip ring or camming sleeve 57, thus axially anchoring such slip ring.
In the annular space defined between the tubular housing 25 and the exterior surface of the isolation sleeve 14, an annular releasing or shearing piston 28 is slidably mounted. O-ring seal means 28a and 28b are respectively provided on the outer and inner surfaces of the annular releasing piston 28. A radial passage 14a is provided in the isolation sleeve 14 at a point adjacent the lower end of the releasing piston 28 to provide tubing bore pressure to the bottom end of piston 28.
The piston 28 is secured in an axially fixed position relative to inner mandrel body 10 by an annular releasing cap 29 which is internally threaded to engage external threads 28c on the top, reduced diameter end of the releasing piston 28. The cap 29 has an internally projecting top flange portion 29a overlying the top end of the reduced diameter threaded portion 28c of the releasing or shear piston 28, and this flange portion 29a, in turn, abuts the lower end surface 13a of the inner body mandrel 10. Movement of the releasing piston 28 relative to body mandrel 10 is prevented by the engagement of the lower surface of the flange 29a with an annular shear ring 30 which has a shearable flange portion 30a embedded in an annular slot 14b provided on the adjacent surface of the isolation sleeve 14.
An annular space 98 is provided around the exterior of the cap 29 of the releasing piston 28, and this annular space is in fluid communication with tubing pressure through a radial port 14c provided in the isolation sleeve 14, an annular recess 28d and one or more radial ports 28f provided in the medial portions of the releasing piston 28. Thus, in the positions of the elements illustrated in Figures 1 a through 1 d, the pressure existing in the tubing bore is transmitted to both sides of the releasing piston 28 and the pressure forces on the releasing piston 28 are essentially balanced, so that the piston 28 remains in the illustrated position relative to the isolation sleeve 14 and the housing 25. It should be further noted that the shear ring 30 effectively limits upward movement of the mandrel 10 relative to the housing 25 to the vertical spacing provided between the releasing piston 28 and an isolation piston 27 mounted in the chamber 98 above the releasing piston 28 and abutting a downwardly facing shoulder 25a on the housing 25. Seals 27a and 27b are provided on the annular isolation piston 27 which cooperate with the outer surface of the inner mandrel body 10 and the inner surface of the housing 25, respectively.
The upper hold-down head 21 cannot move downwardly on the mandrel body 10 in the well insertion position, illustrated in Figures 1a through 1 d, since the outer mandrel structure 15 is releasably connected to the inner mandrel or body 10 by releasable latch means L (Figure 1 c). The packer assembly is therefore maintained in a stretched out condition during running into the well.
The hold-down means 22 is of the fluid pressure operated type, preferably as more particularly disclosed in the above identified US Patent No. 3,131,769. As shown, the hold-down means 22 has 'an internal seal ring 32 between the mandrel body 10 and the upper end 33 of the head 21. A plurality of radial bores 34 in the head 21 below the seal 32 have pistons or anchor buttons 35 reciprocable in the bores 34, and having side or piston rings 36 sealingly engaged therebetween. These pistons or buttons 35 have teeth or wickers 37 on their outer ends engageable with the casing C upon outward movement of the buttons, to anchor the packer P against upward movement in the bore hole after the packer P is set and in the presence of differential fluid pressure from below the packer P.
Each anchor button 35 is appropriately oriented with its wickers or teeth 37 disposed normal to the axis of the cylinder 34 by an orienting and retaining bar 38 extending through a longitudinal slot 39 in each button anchor element opening through its exterior, the retainer bar 38 also extending into upper and lower grooves 40 in the body 21 on opposite sides of the anchor element. The piston retainer bar 38 is suitably secured to the body 21 by screws 41 and supports one or a plurality of biasing beams 43, which may be helical compression springs, mounted in the longitudinal slot 39, the outer ends of which engage the retainer bar 38, and the inner ends of which are disposed in sockets 43 in the anchor element in engagement with an inner face of the latter. As disclosed in the drawings, two longitudinally spaced springs 42 are mounted in each piston anchor or gripping element 35.
The springs 42 urge the anchor elements toward their retracted position. When sufficient pressure is developed in the annular space 44 between the body 10 and the head 21 to overcome the force of the springs 42, the anchor elements 35 are urged outwardly to engage their teeth with the wall of the well casing C. When such pressure is relieved, the springs 42 return the anchor elements 35 to their fully retracted position.
The packing means 23 comprises a plurality of resiliently deformable, eiastomeric rings 45, having tapered abutting surfaces, disposed about the packing mandrel 17 between the lower end shoulder 46 of a skirt 47 of the hold-down head 21 and an upwardly facing shoulder 48 of a tubular expander body 49 forming part of the anchor means 24. This expander body 49 has an
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internal shoulder 50 facing downwardly and seating on an upwardly facing outer shoulder 51 on the mandrel section 17. At its lower end, the expander member 49 has a downwardly and 5 inwardly inclined expander or cone surface 52 cooperative with opposed downwardly and inwardly inclined end surfaces 53 of the anchor slip elements 54. These slips elements 54 have a dove-tailed, sliding connection 55 with the 10 conical and oppositely inclined T-head connections 56 on the upper end of a slip ring or camming sleeve 57 which, as previously mentioned, is threaded at 58 into the upper end of the lower housing 25. A lock screw 59 secures 15 the threaded connection 58.
As previously indicated, the outer mandrel structure 15 is held in an upper position during running, with the anchor slip means retracted, by the releasable latch means L shown in Figure 1 c. 20 This latch means includes a latch element or elements in the form of circumferentially spaced, annular segments 60 bridging between the inner mandrel 10 and the connector mandrel section 16 by mounting in radial openings 61 provided in 25 the mandrel section 1 6. The segments 60 engage in an annular groove 62 provided in the outer surface of the inner mandrel body 10.
The segments 60 are retained in the latching position of figure 1 c by a reduced thickness skirt 30 portion 63 of an annular segment retainer 64 which is disposed between the inner cylindrical wall 25e of the housing 25 and the outer cylindrical wall of the connector mandrel 16. Suitable side ring seals 65 are provided on the 35 opposed walls of segment retainer 64 to cause it to function as a piston, such side ring seals being engaged with the opposed cylindrical walls of the housing 25 and connector mandrel 16. A plurality of shear screws 66 are threaded through the 40 segment retainer piston skirt 63 at a selected number of circumferentially spaced locations and extend into a slot 63a in the connector mandrel 16 to releasably retain the segment retainer piston 64 in the position of Figure 1 c and thereby 45 releasably hold the outer mandrel structure against relative movement on the inner body mandrel 10, since the latching segements 60 are held in the annular groove 62.
Below the segment retainer piston 64 is an 50 annular piston chamber 67 defined between the opposed inner cylindrical wall 25e of the housing 25 and the outer cylindrical walls of the mandrel body 10. An annular piston 69 is mounted on the lower end of the connector mandrel 16 by threads 55 68. The annular piston 69 has inner and outer side ring seals 71 slidably engaging the aforementioned mandrel body and housing cylindrical surfaces. Fluid is admissible to the annular chamber 67 between the pistons 64 and 60 69, through a suitable number of radial ports 10c in the mandrel body 10 which communicate between the bore thereof and the piston chamber 67, and also communicate with radial ports 72 provided in the connector mandrel 1 6. 65 Thus, it is now apparent that the latch means L
can be released by applying, through the tubing T and the mandrel body 10, sufficient fluid pressure to cause an upward force on the latch retaining piston 64 which will shear screws 66 and, move 70 the retaining piston 64 upwardly and allow the segments 60 to move outwardly from their seat 62. In order to accomplish the increase in pressure in the tubing T, conventional means (not shown) for temporarily blanking either the bottom 75 sub 5 or the tubing below the bottom sub 5 is provided, such as a wire line set and manipulated blanking plug. i
Below the upper piston 69, between the housing 25 and the inner body or mandrel 10 80 (Figures 1 c and 1 d) is an annular atmospheric oc low pressure chamber 85 defined between the upper piston 69 and the lower isolation piston 27. Pressure in chamber 85 is determined by the initial assembly of the packer P, hence is usually 85 atmospheric. The isolation piston 27 has a lower annular extension 27c which can move downwardly to contact the shoulder 28e on the releasing piston 28, which, however, is retained against downward movement by the shear sleeve 90 30.
Under the conditions shown in Figure 1d, the annular piston 28 has equal end areas exposed to tubing fluid pressure in the upper and lower annular spaces 98 and 99, is pressure balanced, 95 and exerts no shearing force on the shear ring 30. Accordingly, when the tubing pressure is increased to shear screws 66, the retainer piston 64 moves upwardly to release the latch segments 60. This permits the outer mandrel structure 15 100 to be forced downwardly by the pressure differential across the upper piston 69. Concurrently the inner body mandrel 10 is moved upwardly by the larger differential area thereof below the seal 32 in the head 21 being exposed 105 to the increased tubing pressure, until the isolation piston 27 and the release piston 28 are brought into abutment. Thus, the packer P may be set to the position illustrated in Figures 2a, 2b and 2c.
110 Means are provided which are operable when the packer is set to lock the pack-off force into the resilient packing elements 45. Such means generally designated 101 (Figures 1c and 2b) comprises one way ratchet means, including a 115 resiliently expandable and contractable split lock ring 102 disposed between the inner mandrel -body 10 and the outer mandrel structure 15, and, more specifically, between the mandrel body 10 and the packing mandrel section 17. Co-120 engageable between the body lock ring 102 and the exterior of the mandrel body 10 are threads or ribs 103 on the mandrel body 10 and internal companion threads or ribs 104 within the split body lock ring 102. These threads or ribs are 125 relatively fine and essentially provide roughened contact surfaces which enable the split body lock ring 102 to expand and move downwardly along the inner mandrel body 10. Return movement of the body lock ring 102 upwardly along the 130 mandrel 10 is, however, prevented by companion
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external buttress type threads or ribs 105 on the split lock ring 102, and internal threads or ribs 106 on the interior of the packing mandrel 17, which provide transversely extended abutment 5 surfaces preventing upward movement of the ring 102 with respect to the packing mandrel 17, and downwardly and inwardly inclined wedge surfaces which forceably urge the split lock ring 102 circumferentially inwardly into locking 10 engagement between the ribs or threads 103 and 104 to prevent upward movement of the packing mandrel 17 with respect to the inner mandrel or body 10. Such body locking ring structure, per se, is well known, and an example of such a body . 15 lock is shown and specifically described in U.S. Patent No. 3,311,171. The body locking means 101 allows the packing mandrel 17 to move downwardly with respect to the inner body mandrel 10 and the inner body mandrel 10 to 20 move upwardly during setting of the packer P, and the lock ring 102 locks the pack-off force into the packing element 45 when the packer P is set.
In use, the packer assembly is made up on the tubing string and preferably connected to the 25 upwardly extending tubing T by means of the on-off seal connector S shown in Figures 1 a and 1 b. This onoff seal connector S allows the tubing T to be released from the packer without requiring manipulation of the tubing string in a rotative 30 direction.
In general, the seal connector S comprises a top sub 107 threadably connected at 108 to the tubing string T and having a threaded and sealed joint 109 with the top of an external tubular 35 housing 110 which is connected at its lower end 110a to an internally threaded seal housing 111, which, in turn, is threadably connected to the top ring portion 112a of a collet 112. The seal housing 111 defines an annular space 111a 40 between its internal surface and the polished external cylindrical surface 113a of a hollow seal mandrel 113 within which suitable slip seal elements 114 are mounted.
The seal mandrel 113 is connected at its lower 45 end by threads 115 to the top end of a collet locking sub 116 which, in turn, has its lower end 117 secured by threads to the top end 11 of the inner mandrel body sleeve 10. The top end of the seal mandrel 113 is secured by threads 118 to 50 the lower end of an annular seal nipple 119. The top end 119a of the seal nipple 119 terminates in spaced relationship below a downwardly facing shoulder 107a formed on the top sub 107. The internal contour of the seal nipple 119 is 55 conventionally recessed as indicated at 120 to accommodate a wireline connecting tool (not shown) if required.
The collet locking sub 116 is further provided with a downwardly and inwardly inclined locking 60 surface 116a with which the correspondingly shaped enlarged finger end portions 121 of the collet 112 are respectively engageable. The finger end portions 121 are, of course, resiliently radially shiftable to clear the shoulder 116a during the 65 initial assembly of the on-off connector S. When,
however, the collet locking sub 116 is secured to the inner mandrel body 10, the collet locking fingers 121 are held inwardly in their latched position by the top end 126 of a collet locking 70 sleeve extension 125 which is secured by threads 127 to the top of the hold-down head 21. Thus, the onoff connector S is securely attached to the packer P during the running of the packer P into the well.
75 When however the packer P is set within the well through the application of tubing pressure, in the manner heretofore described, the head 21 moves downwardly and carries with it the collet locking sleeve 125, so that the top end 126 of 80 such sleeve moves below the ends of the enlarged finger portions 121 of the collet locking sub 112, as shown in Figure 2a. The on-off connector S may then be readily removed from the packer P by virtue of the enlarged collet finger 85 end portions 121 sliding outward around the inclined surface 116a provided on the collet locking sub 116 as the tubing string T is lifted.
The external surface 113a of the seal mandrel 113 is of substantial axial extent and is polished 90 so that in the event it is not desired to retrieve the tubing, the sliding sealed engagement between slip elements 114 and the polished cylindrical surface 113a of the seal mandrel 113 accommodates the thermal contraction and 95 expansion of the tubing T. When it is desired to retrieve the tubing, the tubing T is merely pulled out of the well, and it carries with it the seal housing 111 and the locking collet 112.
A significant advantage of the described on-off 100 connector S is the fact that no further wireline manipulations are required after the setting of the packer P. The connector S may be left in place to function as a slip seal if the tubing is not to be pulled or, if the tubing is pulled, the components 105 of the on-off connector S will come out of the well with the tubing.
To set the packer P it is lowered on the tubing string T to a desired setting location within the well casing. With the packer in the setting 110 position, for example, as seen in Figures 1 a through 1 d, it is apparent that fluid can be displaced downwardly through the tubing string and through the bore of the inner body mandrel 10 of the packer P. When it is desired that the 115 packer P be set, the pressure of fluid within the tubing T can be increased by inserting a conventional removable plug, check valve, or other means (not shown) either in the bottom sub 5 or in the tubing connected below the bottom 120 sub 5.
The tubing pressure finds access to the pressure chamber 67 above the annular setting piston 69 through the port 10c in the inner mandrel body 10. Downward movement of the 125 annular piston 69 is prevented by the latching segments 60 engaging in the annular groove 62 on the inner mandrel body 10 and being held therein by the latching piston skirt 63, until such time as the pressure within the chamber 67 130 acting upwardly on the latching piston 64
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provides an upward force thereon in excess of the shear value of the shear screws 66, causing them to be sheared and permitting the piston 64 to move upwardly, thereby allowing the segments 5 60 to be automatically disengaged from the annular groove 62. Further upward movement of the piston 64 is limited by the bottom end of slip ring 57, which is axially fixed by the housing 25.
At this point, the mandrel structure 15 is 10 caused to move downwardly with respect to the inner body or mandrel 10 under the influence of fluid pressure in the chamber 67 acting downwardly on the annular piston 69 and the pressure of fluid in the annulus acting on the 15 mandrel portion 16. Relative upward movement on the inner body mandrel 10 with respect to the outer mandrel structure 15 produced by the tubing pressure is permitted by the body locking ring 102 as it ratches downwardly over the ribs or 20 threads 103 on the mandrel 10. The downward movement of the mandrel structure 15, which is coupled to the hold-down means 22, moves the packing engaging upper shoulder 46 downwardly towards the upwardly facing shoulder 48 25 provided by the expander member 49. The setting force is derived from the hydrostatic and applied tubing pressure acting on the differential area between the seal rings 65 and annulus pressure acting on the area of the mandrel 15 between the 30 seal ring 65 and the opposed seal rings 71. This setting force is transmitted through the packing elements 45 to the expander member 49, thereby wedging the slips 54 outwardly relative to the fixed slip ring 57 to cause engagement of the 35 teeth thereon with the well casing. Thereafter, the packing elements 45 are resiliently deformed axially and circumferentially outwardly into sealing and packed-off engagement within the casing C. An increase in the tubing pressure can 40 then be applied to the conventional blanking or other pressure holding means (not shown), by which the tubing pressure was originally permitted to develop, to release such means and permit the tubing pressure to be reduced. 45 The packer P is thus firmly set and anchored in the casing C and the force required to effect the pack-off is trapped or locked in the resilient packing elements 45 by virtue of the one-way lock between the body lock ring 102 and the 50 packing mandrel 17 and the body 10, and the blocking of upward movement of mandrel 10 relative to housing 25 by shear ring 30.
In the event that pressure below the set and anchored packer P exceeds the pressure in the 55 annulus above the packer P, such pressure finds access between the packing mandrel 17 and the inner mandrel body 10 to the hold-down piston chambers 34 and can act upon the hold-down slips or anchors 35 to force them radially 60 outwardly into engagement with the casing C, to prevent such differential pressure from moving the packer assembly upwardly within the well casing C. With the packer P in the set position, any downward force applied to the mandrel body 65 10 will be transmitted through the body lock ring
102 to the packing mandrel 1 5, causing the transmission of such force through the packing to the anchor slips. Any upward tension imposed on the tubing T will be transmitted through the mandrel body 10 and the shear ring 30 to the housing 25, and thus to the slips 54, following contact of the shear piston 28 with the lower end face 27d of the piston 27, which forms the atmospheric chamber 85, as seen in Figure 2c.
Fluid pressure actuated means are provided for releasing the packer P from its anchor set position in the well casing C. As seen in Figures 3a and 3b a releasing tool RT is adapted to be lowered through the pipe string or the tubing T on a f wireline. The releasing tool RT comprises an outer body structure, including a lower sealing sleeve 130 having suitable packing means 131 carried thereby between and upwardly facing shoulder 132 on the sleeve 130 and the downwardly facing end 133 of an intermediate sealing sleeve 134. The intermediate sealing sleeve 134 is threadably connected to the lower sealing sleeve by a suitable threaded connection 135 and carries an annular packing 136 between an upwardly facing shoulder 137 and the downwardly facing end 138 of an upper sealing sleeve 139. The upper sealing sleeve 139 is suitably connected by a plurality of bolts 139a to an annular groove 140a in a fishing neck 140 which provides a downwardly facing shoulder 141 adapted for engagement by the usual wireline running and retrieving tool to lower the releasing tool RT into engagement with the packer P.
Immediate the connection 138 between the two sealing sleeves, the tool RT has a downwardly facing shoulder 142 adapted to engage the upwardly facing landing shoulder 14e provided wrthin the isolation sleeve 14 of the packer assembly, whereby the axially spaced packings 131 and 136 are caused to straddle the ports 14a in the isolation sleeve 14. Below the packing 136, the sealing sleeve 134 has a number of radial ports 144 which communicate with the ports 14a above an internal annular sealing flange 145 having an internal side ring seal 146 slidably and sealingly engaged with an internal cylindrical surface portion 147a of an elongated, inner tubular mandrel 147.
The mandrel 147 is connected to a lower sleeve extension 149 of a fishing neck 140 by a suitable shear pin 148, which traverses a check. valve chamber 150 in the mandrel 147, which includes a ball valve 150a.
The lower portions of the mandrel 147 lie in s inwardly spaced relationship with respect to the inner surface of the lower sealing sleeve 130 and thus define a chamber 151 which is maintained at atmospheric pressure existing during the assembly of the releasing tool RT. The lower end of the atmospheric chamber 151 is closed by an upwardly extended section 152 of a lower head 153 which is threaded into the lower sealing sleeve 130, as at 154, and has an inner side ring seal 155 and an outer side ring seal 156 sealingly engaged respectively with the outer cylindrical
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surface of the mandrel 147 and the lower cylindrical bore of the sealing sleeve 130. The internal surface of the mandrel 147 is recessed as indicated at 157 immediately above the sealing 5 surface 147a.
With the releasing tool RT in place, the upper port 14c in the isolation sleeve 14 is open to the fluid within the tubing strings through ports 140b in the fishing neck 140, and with the releasing 10 tool mandrel 147 in the position of Figure 3b, the port 14a is isolated by seals 131 and 136, and the releasing piston 28 remains pressure balanced. However, upon downward movement r of the mandrel 147 from the position of Figure 3b . 15 to the position of Figure 4a, communication is established between the lower port 144 in the sealing sleeve 134, which communicates with the release piston chamber 99 below the release piston 28, and the atmospheric chamber 151. 20 Downward movement of the inner mandrel
147 is produced by increasing the tubing pressure to a level to effect the shearing of the shear pin
148 and permit the mandrel 147 to move to its lower position, shown in Figure 4a. In this
25 position, the pressure against the lower side of the release piston 28 is substantially reduced by the fluid connection established to the atmospheric chamber 151 contained in the releasing tool RT. Hence, the top side of the 30 sealing piston 28 is subjected to an increasing downward force as tubing pressure increases until sufficient force is generated to effect the shearing of the locking ring portion 30a of the shear ring 30, thus permitting the piston 28 to 35 move downwardly into abutment with the uppermost surface of the bottom sub 5 as shown in Figure 4a.
Referring now to Figure 4a, it will be seen that when the releasing tool mandrel 147 is moved 40 downwardly by fluid pressure following shearing of the shear pin 148, a cylindrical sealing surface 159a on the mandrel 147, above the annular groove 157, moves into the sealing flange 159 and is engaged by the resilient side ring seal 159b 45 in the flange. The lower cylindrical sealing surface 147a which was initially engaged within the sealing ring 146 of the sealing flange 145, is moved downwardly from sealing engagement with the seal ring 146, and the latter is bridged by 50 the external groove or recess 157 in the mandrel 147. The groove 1 57 accordingly establishes communication between the atmospheric chamber 151, radial ports 144 and radial ports 14a which communicate with the release piston 55 chamber 99. Thus, the pressure from the chamber 99 is bled off into the atmospheric chamber 151, while the hydrostatic pressure of fluid in the tubing above the packer assembly is applied to the upper end of the release piston 28 in the 60 chamber 98 via the radial ports 14c in the isolation sleeve 14. If the hydrostatic pressure of fluid within the tubing string is insufficient to cause downward movement of the shear piston 28 with resultant shearing of the shear ring 30, 65 additional fluid pressure can be applied to the tubing to cause such downward movement of the piston 28 and shearing of the shear ring 30, as illustrated in Figure 4a.
After the shear ring 30 has been sheared, the 70 tubing T can be elevated, so that, as can be ssen from Figure 4a, the chamber 98 communicates with the tubing through the port 14c, and the setting force is relieved. An external, upwardly facing shoulder 10a, shown in Figure 1 c, on the 75 inner mandrel or body 10 engages beneath an internal downwardly facing shoulder 16a within the outer mandrel structure 15, and more particularly, at the connection between the connector mandrel 16 and the packing mandrel 80 17. The body I6ck ring 102 permits the body 10 to ratchet upwardly through the lock ring, and upon coengagement of the opposing shoulders 10a and 16a, the reduced diameter section 10b of the body 10 is disposed within the holddown 85 head 21, so that hydrostatic pressure is equalised across the holddown pistons or buttons 35, and the latter are returned to their normally retracted positions by the return springs 42. The outer mandrel structure 1 5 then moves upwardly with 90 the inner body 10, effecting retraction of the anchor slips 54 and allowing the resilient packing elements 45 to resume their normal condition, so that the packing assembly can be retrieved from the well casing C.
95 In the event that tubing pressure cannot be developed within the tubing, or the release of the packer P cannot be accomplished by the increase in tubing pressure, the packer P may nevertheless be mechanically released. A conventional 100 connecting tool, (not shown) is lowered through ' the tubing string to effect engagement with the recess 120 of the seal nipple 119 which, is rigidly connected to the inner mandrel body 10. Exertion of an upward force by the wireline on the inner 105 mandrel body 10 will then have the effect of moving the releasing piston 28 into abutting engagement with the lower end of the isolation piston 27, thus effecting the shearing of the shear ring 30, and permitting the inner mandrel body 10 110 to move upwardly relative to the outer mandrel structure 15 until the external shoulder 10a on the inner mandrel body 10 engages the downwardly facing shoulder 15 is elevated to release the setting forces on the packing 23 and 115 the slip 24. Following such release, the entire packer assembly can be readily removed from the well casing.
From the foregoing, it will be seen that the present invention provides a pressure set and 120 locked casing packer with release means also entirely actuated by fluid pressure, where the packer can be advantageously employed in a variety of applications where manipulation of the tubing is not possible or practical.
125 If for any reason the packer fails to release upon the increase in tubing pressure, or if sufficient tubing pressure can not be generated, the packer can nevertheless be released and retrieved mechanically by lowering a connecting 130 tool on a work string to engage a nipple element
8
GB 2 080 368 A 8
connected to the inner body mandrel, following which the packer may be released by upward force exerted on the inner body mandrel by the work string.
Claims (14)
1. A packer that can be fitted within a well conduit and which includes an elongated tubular body that can be connected to a running tubing string and that comprises co-axial relatively
10 movable inner and outer mandrels, normally retracted slip means on the tubular body and that may be expanded into engagement with the conduit, resilient packing means on the body and that may be deformed into sealing engagement 15 with the conduit, means responsive to the pressure of fluid in the bore of the body for producing relative axial movement of the mandrels, a member adjacent the lower portions of the outer mandrel and extending axially below 20 the end of the inner mandrel, and means mounted on the member for closing fluid passage through the packer, whereby tubing pressure may then be raised and the inner mandrel may be shifted axially relative to the outer mandrel under the 25 influence of the tubing pressure to facilitate the action of the pressure responsive means.
2. A packer according to claim 1 further comprising a slip camming sleeve surrounding the outer mandrel and means for securing the
30 member to the slip camming sleeve, thereby fixing the axial position of the slip camming sleeve.
3. A packer according to claim 1 in which the means responsive to fluid pressure in the bore are
35 responsive to increased fluid pressure for axially shifting the outer mandrel relative to the inner mandrel and in which the packer includes setting means mounted on the outer mandrel for expanding the slip means and deforming the 40 packing means, the setting means including the said member and a camming sleeve surrounding said outer mandrel but axially movable relative thereto, sleeve means for connecting said member to said camming sleeve, thereby axially 45 positioning said camming sleeve, locking means for holding the outer and inner mandrels in their pressure shifted position, and means responsive to the relative movement of said outer and inner mandrels with respect to the camming sleeve for 50 operating the setting means.
4. A packer according to claim 3 also comprising latch means releasably responsive to fluid pressure in the tubing to prevent relative movement of the mandrels until the fluid pressure
55 reaches a predetermined level.
5. A packer according to claim 1 in which the inner mandrel is an elongated tubular body, the outer mandrel is longitudinally shiftable on the inner mandrel body and the packing and slip
60 means are on the outer mandrel, and which also includes locking means permitting relative longitudinal shifting of the outer mandrel in one direction with respect to the inner mandrel body and preventing relative longitudinal shifting in the other direction, and in which there is a camming sleeve engageable with the slip means upon the occurrence of the relative longitudinal shifting of the outer mandrel structure with respect to the inner mandrel body in the one direction, an elongated sleeve connected at its top end to the camming sleeve and at its lower end to the said member which extends beyond the lower ends of both the inner mandrel body and the outer mandrel structure, the sleeve being radially spaced from the inner mandrel bodyand defining an annular pressure chamber that serves as the ! pressure responsive means, latching means for * securing said outer mandrel structure to said inner mandrel body and an unlatching piston « disposed in said annular chamber and operable by an increase in tubing pressure to release the latching means and fluid pressure means from the bore to the annular chamber and in which the means for closing the fluid passage through the member permit fluid pressure within the bore of the inner mandrel to be increased to a predetermined level effective to release the latching means.
6. A packer according to claim 5 in which the annular fluid chamber also includes a packing release piston disposed between two additional axially spaced fluid passage means leading from said bore into said chamber, release means insertable in the inner mandrel body and having a low pressure chamber and a member shiftable from one position at which each passage means is in communication between the bore of the inner mandrel body and the release piston chamber to another position at which only one of the passage means communicates with the low pressure chamber, thereby producing an axial shifting of the release piston, and releasable means on the inner mandrel body engageable by the piston to release the inner mandrel body for upward movement to release the packing means and the slip means.
7. A packer according to claim 6 in which the releasable means are a shearable member engaged by the release piston.
8. A packer according to claim 6 in which the release means are removably supported in the inner mandrel body and there are means connectable to a running tool for removable disposal of the release means from the body. .
9. A packer according to any of claims 5 to 8 „ including an isolation sleeve secured to the bottom end of the inner mandrel body and 0 slidably engageable with the interior of the member, and two additional fluid passage means formed in the isolation sleeve.
10. A packer according to any of claims 1 to 8 including an isolation sleeve secured to the bottom end of the inner mandrel and slidably engageable with the inner bore of the member.
11. A packer according to any preceding claim in which the member surrounds the lower portions of the outer mandrel.
12. A packer according to any preceding claim
65
70
75
80
85
90
95
100
105
110
115
120
125
9
GB 2 080 368 A 9
in which expansion of the slip means and operation of the resilient packing mean is by relative axial movement of the mandrels and, when the packer is fitted in the conduit, the raised 5 tubing pressure shifts the inner mandrel axially upward.
13. A packer according to any preceding claim in which the expansion of the slip means is by radial shifting of the slip means and the
10 deformation of the packing means is outward deformation.
14. A packer according to any preceding claim in which the upper end of the inner mandrel body is provided with means for the connection with a 15 wireline and the packer is constructed such that application of an upward force by the wireline to the inner mandrel body will effect the mechanical release of the packer
Printed for Her Majesty's Stationery Office by the Courier Press, Leamington Spa, 1982. Published by the Patent Office, 25 Southampton Buildings, London, WC2A 1 AY, from which copies may be obtained.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US06/168,961 US4311195A (en) | 1980-07-14 | 1980-07-14 | Hydraulically set well packer |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| GB2080368A true GB2080368A (en) | 1982-02-03 |
| GB2080368B GB2080368B (en) | 1984-10-10 |
Family
ID=22613708
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB8121566A Expired GB2080368B (en) | 1980-07-14 | 1981-07-13 | Hydraulically set well packer |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US4311195A (en) |
| CA (1) | CA1165228A (en) |
| GB (1) | GB2080368B (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2530168A (en) * | 2014-09-10 | 2016-03-16 | Baker Hughes Inc | Interventionless method of setting a casing to casing annular packer |
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| US4505332A (en) * | 1982-10-21 | 1985-03-19 | Ava International Corporation | Well packers |
| US4745971A (en) * | 1983-04-29 | 1988-05-24 | Ava International Corporation | Multiple string well packer |
| US4754812A (en) * | 1987-03-23 | 1988-07-05 | Baker Oil Tools, Inc. | Dual string packer method and apparatus |
| US5044433A (en) * | 1990-08-28 | 1991-09-03 | Baker Hughes Incorporated | Pack-off well apparatus with straight shear release |
| US7147068B2 (en) * | 1994-10-14 | 2006-12-12 | Weatherford / Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
| US7100710B2 (en) * | 1994-10-14 | 2006-09-05 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
| US6868906B1 (en) * | 1994-10-14 | 2005-03-22 | Weatherford/Lamb, Inc. | Closed-loop conveyance systems for well servicing |
| US7040420B2 (en) * | 1994-10-14 | 2006-05-09 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
| US7013997B2 (en) * | 1994-10-14 | 2006-03-21 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
| US7108084B2 (en) * | 1994-10-14 | 2006-09-19 | Weatherford/Lamb, Inc. | Methods and apparatus for cementing drill strings in place for one pass drilling and completion of oil and gas wells |
| US5542475A (en) * | 1994-12-01 | 1996-08-06 | Cooper Cameron Corporation | Blanking plug assembly |
| US5893413A (en) * | 1996-07-16 | 1999-04-13 | Baker Hughes Incorporated | Hydrostatic tool with electrically operated setting mechanism |
| US5810082A (en) * | 1996-08-30 | 1998-09-22 | Baker Hughes Incorporated | Hydrostatically actuated packer |
| US6536520B1 (en) * | 2000-04-17 | 2003-03-25 | Weatherford/Lamb, Inc. | Top drive casing system |
| US7140445B2 (en) * | 1997-09-02 | 2006-11-28 | Weatherford/Lamb, Inc. | Method and apparatus for drilling with casing |
| US6742596B2 (en) * | 2001-05-17 | 2004-06-01 | Weatherford/Lamb, Inc. | Apparatus and methods for tubular makeup interlock |
| GB9815809D0 (en) * | 1998-07-22 | 1998-09-16 | Appleton Robert P | Casing running tool |
| GB2340857A (en) * | 1998-08-24 | 2000-03-01 | Weatherford Lamb | An apparatus for facilitating the connection of tubulars and alignment with a top drive |
| DE69926802D1 (en) * | 1998-12-22 | 2005-09-22 | Weatherford Lamb | METHOD AND DEVICE FOR PROFILING AND CONNECTING PIPES |
| US7188687B2 (en) * | 1998-12-22 | 2007-03-13 | Weatherford/Lamb, Inc. | Downhole filter |
| GB2347441B (en) * | 1998-12-24 | 2003-03-05 | Weatherford Lamb | Apparatus and method for facilitating the connection of tubulars using a top drive |
| GB2345074A (en) * | 1998-12-24 | 2000-06-28 | Weatherford Lamb | Floating joint to facilitate the connection of tubulars using a top drive |
| US6896075B2 (en) * | 2002-10-11 | 2005-05-24 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling with casing |
| US7311148B2 (en) * | 1999-02-25 | 2007-12-25 | Weatherford/Lamb, Inc. | Methods and apparatus for wellbore construction and completion |
| US6315041B1 (en) * | 1999-04-15 | 2001-11-13 | Stephen L. Carlisle | Multi-zone isolation tool and method of stimulating and testing a subterranean well |
| EP1242711B1 (en) * | 1999-12-22 | 2006-08-16 | Weatherford/Lamb, Inc. | Drilling bit for drilling while running casing |
| US20060124306A1 (en) * | 2000-01-19 | 2006-06-15 | Vail William B Iii | Installation of one-way valve after removal of retrievable drill bit to complete oil and gas wells |
| US7334650B2 (en) * | 2000-04-13 | 2008-02-26 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling a wellbore using casing |
| US7325610B2 (en) * | 2000-04-17 | 2008-02-05 | Weatherford/Lamb, Inc. | Methods and apparatus for handling and drilling with tubulars or casing |
| GB0010378D0 (en) * | 2000-04-28 | 2000-06-14 | Bbl Downhole Tools Ltd | Expandable apparatus for drift and reaming a borehole |
| GB2365463B (en) * | 2000-08-01 | 2005-02-16 | Renovus Ltd | Drilling method |
| WO2002079605A1 (en) * | 2001-03-29 | 2002-10-10 | Tesco Corporation | Downhole axial force generating tool |
| GB0206227D0 (en) * | 2002-03-16 | 2002-05-01 | Weatherford Lamb | Bore-lining and drilling |
| US6994176B2 (en) * | 2002-07-29 | 2006-02-07 | Weatherford/Lamb, Inc. | Adjustable rotating guides for spider or elevator |
| US7730965B2 (en) | 2002-12-13 | 2010-06-08 | Weatherford/Lamb, Inc. | Retractable joint and cementing shoe for use in completing a wellbore |
| US6899186B2 (en) * | 2002-12-13 | 2005-05-31 | Weatherford/Lamb, Inc. | Apparatus and method of drilling with casing |
| US7303022B2 (en) * | 2002-10-11 | 2007-12-04 | Weatherford/Lamb, Inc. | Wired casing |
| US7128154B2 (en) * | 2003-01-30 | 2006-10-31 | Weatherford/Lamb, Inc. | Single-direction cementing plug |
| USRE42877E1 (en) | 2003-02-07 | 2011-11-01 | Weatherford/Lamb, Inc. | Methods and apparatus for wellbore construction and completion |
| GB2414502B (en) * | 2003-02-27 | 2007-10-17 | Weatherford Lamb | Drill shoe |
| WO2004079150A2 (en) * | 2003-03-05 | 2004-09-16 | Weatherford/Lamb, Inc. | Full bore lined wellbores |
| CA2677247C (en) * | 2003-03-05 | 2012-09-25 | Weatherford/Lamb, Inc. | Casing running and drilling system |
| US7503397B2 (en) * | 2004-07-30 | 2009-03-17 | Weatherford/Lamb, Inc. | Apparatus and methods of setting and retrieving casing with drilling latch and bottom hole assembly |
| CA2517978C (en) * | 2003-03-05 | 2009-07-14 | Weatherford/Lamb, Inc. | Drilling with casing latch |
| GB2414759B (en) * | 2003-04-04 | 2007-11-07 | Weatherford Lamb | Method and apparatus for handling wellbore tubulars |
| US7650944B1 (en) | 2003-07-11 | 2010-01-26 | Weatherford/Lamb, Inc. | Vessel for well intervention |
| US7264067B2 (en) * | 2003-10-03 | 2007-09-04 | Weatherford/Lamb, Inc. | Method of drilling and completing multiple wellbores inside a single caisson |
| GB2424432B (en) * | 2005-02-28 | 2010-03-17 | Weatherford Lamb | Deep water drilling with casing |
| WO2007134255A2 (en) * | 2006-05-12 | 2007-11-22 | Weatherford/Lamb, Inc. | Stage cementing methods used in casing while drilling |
| US8276689B2 (en) * | 2006-05-22 | 2012-10-02 | Weatherford/Lamb, Inc. | Methods and apparatus for drilling with casing |
| US7766089B2 (en) * | 2007-03-16 | 2010-08-03 | Baker Hughes Incorporated | Packer system and method |
| US7735562B2 (en) * | 2007-04-12 | 2010-06-15 | Baker Hughes Incorporated | Tieback seal system and method |
| US8561709B2 (en) * | 2007-04-12 | 2013-10-22 | Baker Hughes Incorporated | Liner top packer seal assembly and method |
| US8550177B2 (en) * | 2011-01-25 | 2013-10-08 | Halliburton Energy Services, Inc. | Packer assembly |
| CN102996089B (en) * | 2012-11-24 | 2015-05-13 | 西南石油大学 | Multi-stage hydraulic expansion tail pipe suspension system with reducing expansion cone for horizontal well for thermal recovery of heavy oil |
| CN104343410B (en) * | 2014-08-06 | 2016-08-17 | 中国石油化工股份有限公司 | Bidirectional bearing compression hydraulic packer |
| CN104806193B (en) * | 2015-05-08 | 2017-12-08 | 中国海洋石油总公司 | A kind of packer |
| US10513898B2 (en) * | 2016-10-26 | 2019-12-24 | Allamon Properties Llc | Hybrid liner hanger and setting tool |
| WO2020013949A1 (en) * | 2018-07-13 | 2020-01-16 | Kingdom Downhole Tools, Llc | One run setting tool |
| CA3033698A1 (en) | 2018-10-10 | 2020-04-10 | Repeat Precision, Llc | Setting tools and assemblies for setting a downhole isolation device such as a frac plug |
| US11761280B2 (en) * | 2021-11-29 | 2023-09-19 | Baker Hughes Oilfield Operations Llc | Interlock for a downhole tool |
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|---|---|---|---|---|
| US3142338A (en) * | 1960-11-14 | 1964-07-28 | Cicero C Brown | Well tools |
| US3112796A (en) * | 1961-03-30 | 1963-12-03 | Baker Oil Tools Inc | Hydraulically actuated well packers |
| US3282342A (en) * | 1963-11-21 | 1966-11-01 | C C Brown | Well packer |
| US4216827A (en) * | 1978-05-18 | 1980-08-12 | Crowe Talmadge L | Fluid pressure set and released well packer apparatus |
| US4263968A (en) * | 1980-03-11 | 1981-04-28 | Camco, Incorporated | Hydraulic set and straight pull release well packer |
| US4285400A (en) * | 1980-07-14 | 1981-08-25 | Baker International Corporation | Releasing tool for pressure activated packer |
-
1980
- 1980-07-14 US US06/168,961 patent/US4311195A/en not_active Expired - Lifetime
-
1981
- 1981-07-03 CA CA000381110A patent/CA1165228A/en not_active Expired
- 1981-07-13 GB GB8121566A patent/GB2080368B/en not_active Expired
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB2530168A (en) * | 2014-09-10 | 2016-03-16 | Baker Hughes Inc | Interventionless method of setting a casing to casing annular packer |
| US9580989B2 (en) | 2014-09-10 | 2017-02-28 | Baker Hughes Incorporated | Interventionless method of setting a casing to casing annular packer |
| GB2530168B (en) * | 2014-09-10 | 2017-10-04 | Baker Hughes Inc | Interventionless annular packer set by a piston in a chamber |
Also Published As
| Publication number | Publication date |
|---|---|
| GB2080368B (en) | 1984-10-10 |
| CA1165228A (en) | 1984-04-10 |
| US4311195A (en) | 1982-01-19 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PCNP | Patent ceased through non-payment of renewal fee |